Quarter turn tubing anchor catcher

ABSTRACT

A torque anchor for anchoring well equipment in a well conduit to arrest movement in both longitudinal directions and rotation in a first direction, but not rotation in an opposed second direction. A mandrel connected to the equipment has one or more grooves for slideably receiving respective pins from a drag body on the mandrel. A slip cage on the mandrel houses slips for selectively engaging and disengaging the conduit. Manipulation of the mandrel at surface causes the pins to move within the one or more grooves on the mandrel and the drag body to move toward the slip retainer driving the slips outward to grip the conduit. Further pulling at surface maintains the set position. The anchor is unseta surface by releasing the pull, rotating the mandrel in the second direction, and pushing the mandrel to disengage the slips.

CROSS REFERENCE TO RELATED APPLICATIONS

This application claims priority from Canadian Patent Application No.2,854,409 filed Jun. 14, 2014 entitled Quarter Turn Torque Anchor andCatcher. This application is also a continuation-in-part of UnitedStates patent application Ser. No. 14/311,322 filed Jun. 22, 2014 andentitled Quarter Turn Torque Anchor and Catcher, which is itself acontinuation-in-part of U.S. patent application Ser. No. 13/716,075filed on Dec. 14, 2012 and entitled Quarter Turn Tension Torque Anchor.The entire disclosures of these priority documents and all relatedapplications or patents are incorporated herein by reference.

FIELD OF THE INVENTION

The present invention relates to tools for petroleum wells generally,including wells accessing heavy crude. In particular, the presentinvention relates to a tubing anchor catcher and its use in a system forreducing movement, which may be caused by a downhole pump, within in awell conduit.

BACKGROUND OF THE INVENTION

A tubing string is used within a petroleum well to position downholetools proximal to one or more underground geological formations thatcontain petroleum fluids of interest. The tubing string may also bereferred to as production tubing or a production string. The tubingstring is made up of sections of individual pipe joints that aretypically threadedly connected to each other. The tubing string extendswithin a bore of the well. The well bore is typically completed withcasing or liners. The completed well bore may also be referred to as awell conduit. The tubing string can carry various downhole tools intothe well conduit. For example, downhole tools can be used for variouspurposes including anchoring the tubing string within the wellbore at adesired location and to limit movement of the tubing string. Downholetools can also be used to stimulate and capture production of petroleumfluids. The tubing string is also the primary conduit for conducting thepetroleum fluids to the surface.

Known tubing anchors use either a combination of right and left handthreads, or are limited to one thread orientation. Examples of suchtubing anchors are shown in U.S. Pat. No. 3,077,933 to Bigelow and inCanadian patent no. 933,089 to Conrad. Disadvantages of such tubinganchors include the expense of manufacturing the threaded portions, thethreads may be susceptible to corrosion and the threads may be difficultto, or unable to, unset if they become filled with sand or corroded.With the new technology of fracing, the industry has adopted a heavierweight casing to be able to handle the bends and ‘S’ curves that aredrilled today. A heavier weight casing wall makes the interior diameterof the casing smaller. This change in diameter, combined with the wellsdrilled with deviations and horizontal applications, makes the settingof the older design (multiple revolutions) tubing anchor catchers andpackers hard to set as it is hard to feel, or detect, at surface whenthe tools is set due to the friction on the side walls and having toworkout the tubing twist going around bends in the well bore.

Another type of tubing anchor shown in U.S. Pat. No. 5,771,969 andcorresponding Canadian patent no. 2,160,647 to Garay avoids theaforementioned threads and instead uses a helical bearing to transformrotational movement into linear movement for setting and unsetting thetubing anchor. The helical bearing also accommodates shear pins forsecondary unsetting if required. The use of one component, namely thehelical bearing, to perform several functions has the advantage over theprevious prior art of being less expensive to manufacture and lesssusceptible to seizing.

SUMMARY OF THE PRESENT INVENTION

The present invention provides a tubing anchor catcher that acts toreduce or stop movement of a tubing string within a wellbore. The tubinganchor catcher may also catch the tubing string and hold the tubingstring in place if a part of the tubing string disconnects or failsabove tubing anchor catcher.

One example embodiment of the present invention provides a tubing anchorcatcher tool that is positionable within a well conduit for preventingmovement of a tubing string. The tool comprises: a mandrel that isconnectible at either end to the tubing string, the mandrel comprising agroove; a first cone element that is slidably mountable on to themandrel, the first cone element comprising a first conical surface; adrag body that is slidably mountable on the mandrel, the drag bodycomprising a drag member that is sized for frictionally engaging aninner surface of the well conduit, a pin for engaging the groove, and asecond conical surface; a biasing member that is slidably mountable onthe mandrel adjacent the drag body for engaging the first cone elementwhen the biasing member is compressed; and a slip cage that is slidablymountable on the mandrel, the slip cage comprising a slip that isadapted for engaging the inner surface of the well conduit when themandrel is rotated a quarter turn relative to the drag body and theconical surface is disposed underneath the slip. Wherein when the secondcone element is engaged, the second cone element is slidably moveableunderneath the slip.

BRIEF DESCRIPTION OF THE DRAWING FIGURES

Embodiments of the invention will now be described, by way of exampleonly, with reference to the accompanying drawings, wherein:

FIG. 1 is an elevation side view of an example embodiment of a tubinganchor catcher;

FIG. 2 is a mid-line cross-sectional view taken along line 2-2 in FIG.1;

FIG. 3 is a mid-line cross-sectional view of FIG. 1 showing the tubinganchor catcher with its slips extended;

FIG. 4 is a perspective view of an example embodiment of a mandrel foruse as part of the tubing anchor catcher of FIG. 1;

FIG. 5 is an enlarged view of an example embodiment of a groove thatforms part of the mandrel of FIG. 4, showing a pin from the tubinganchor catcher engaged in the groove, in a run-in position;

FIG. 6 is the view of FIG. 5 showing the pin in a set position;

FIG. 7 is a mid-line cross-sectional view of an example embodiment of atubing anchor catcher, in the run-in position;

FIG. 8 is a mid-line cross-sectional view of the tubing anchor catcherof FIG. 7, in the set position;

FIG. 9 is a side elevation view of an example embodiment of a tubinganchor catcher;

FIG. 10 is a mid-line, sectional view of the tubing anchor catcher ofFIG. 9; and,

FIG. 11 is an exploded isometric view of the tubing anchor catcher ofFIG. 9.

FIG. 12 is an enlarged view of a portion of FIG. 12.

FIG. 13 is a side elevation view of an example embodiment of a tubinganchor catcher positioned within a well bore.

FIG. 14 is a cross-sectional view taken along line 14-14 in FIG. 13.

DESCRIPTION OF PREFERRED EMBODIMENTS

FIGS. 1 to 8 depict one example embodiment of a tubing anchor catcher10. The tubing anchor catcher 10 may be inserted within a well conduit12 (see FIGS. 13 and 14), such as a wellbore casing. FIGS. 1 and 2depict the tubing anchor catcher 10 in an unset, or “run-in”,orientation in which it can be run inside the well conduit 12 on atubing string. Safety subs 14A, B may be attached to a mandrel 20 of thetubing anchor catcher 10 having attachment means, such as an innerthreaded lower end 22 and an outer threaded upper end 24. In thisembodiment, the tubing anchor catcher 10 may be run down the wellconduit 12 while being threadedly connected within the tubing string inthe downhole direction indicated by arrow 16. Arrow 17 indicates theopposite direction within the well conduit 12, namely the up-holedirection. It is noted, however, that terms such as “up”, “down”,“forward”, “backward” and the like are used to identify certain featuresof the tubing anchor catcher 10 when placed in a well conduit. Theseterms are not intended to limit the tubing anchor catcher's use ororientation. Further, when describing the invention, all terms notdefined herein have their common art-recognized meaning.

The tubing anchor catcher 10 has an upper end 10A and a lower end 10B.The tubing anchor catcher 10 may comprise of a drag body 40, a slip cage60 and a biasing member 94, all of which are mounted about the externalsurface of the mandrel 20. The drag body 40 houses a drag means, in theform of one or more drag blocks 42, for spacing the tubing anchorcatcher 10 away from the inner wall 13 of the conduit 12. The dragblocks 42, for example three or four drag blocks 42, may be generallyevenly spaced circumferentially about the tubing anchor catcher 10. Eachdrag block 42 has a drag spring to urge the outer surface 46 of the dragblock against the well conduit's inner wall. Upper and lower dragretaining rings 48, 50 keep the drag blocks 42 removably mounted withinthe drag body 40. In addition to keeping the tubing anchor catcher 10spaced from the well conduit 12, the contact of the drag block surface46 the well conduit's 12 inner wall or surface 13 causes friction thaturges the drag body 40 to remain stationary while the mandrel 20 moveswithin the rest of the tubing anchor catcher 10.

As will be discussed further, the drag body 40 is connected to themandrel 20 by one or more pins 88 that extends inwardly from the dragbody's 40 inner surface to engage an externally facing groove 80 that ison the outer surface of the mandrel 20. As described further below, inone example embodiment, the pins 88 are made from a shearable material.

The slip cage 60, which may also be referred to as a slip retainer, isalso mounted on the mandrel 20 adjacent the drag body 40. In particular,the slip cage 60 is mounted on the mandrel 20 above the drag body 40(i.e. in direction 17). The slip cage 60 may house one or more radially,movable slips 62. For example, three slips 62 are depicted as beingevenly spaced about the slip cage 60, although this is not intended tobe limiting as the tubing anchor catcher 10 described herein may operatewith one or more slips 62. Each slip 62 has an outer surface with teeth63 for gripping the inner wall 13 upon contact. The teeth 63 maycomprise upward gripping teeth 63B and downward gripping teeth 63A. Theslip 62 may also have an inner surface with opposed, outwardly inclinededges with an upper edge 64A and a lower edge 64B. A fastener in theform of a socket head cap screw 65 is fastened to the drag body 40 andis located within each of a plurality of associated elongate slots 66that are defined by the slip cage 60 and spaced circumferentiallythereabout, preferably between each slip 62. The cap screw 65 is adaptedto contact upper and lower shoulders 68A, B at each end of theassociated slots 66, which forms a stop means to prevent the slip cage60, and the drag body 40, from longitudinally separating.

A cone element 70 is mounted about the mandrel 20 at an upper end of theslip cage 60. The cone element 70 comprises an upper edge 70A and alower edge 70B. The lower edge 70B forms a first conical surface whoseinclined surface wedges under the slips 62 when the tubing anchorcatcher 10 is moved into a set position. Likewise, an upper edge of thedrag body 40 forms a second conical surface 54 whose inclined surfacealso wedges under the slips 62 when the tubing anchor catcher 10 ismoved into a set position. However, the first and second conicalsurfaces 70B, 54 may not actively contact the slips in the unsetposition. A slip spring 76 urges each slip 62 radially inwardly into theslip cage 60 and away from the well conduit 12 while in the unsetposition (FIG. 2).

FIG. 3 depicts the tubing anchor catcher 10 in the set position with theslips 62 extended outwardly from the slip cage 60 for engaging the innersurface 13 of the well conduit 12. The slips 62 are extended due toeither or both of the conical surfaces 70B, 54 moving underneath theslips 62. For example, when the conical surface 54 moves underneath theslip 62, the spring 94 may be compressed, from below due to the movementof the mandrel and the tension in the tubing string, and force the firstconical surface 70B underneath the slip 62.

FIG. 4 depicts the mandrel 20 as including an upper end 20A and a lowerend 20B. As described above, the upper and lower ends 20A, B may eachcomprise threaded connections for connecting the mandrel 20 to thetubing string. As shown in FIG. 2, the upper end 20A comprises a boxthreading and the lower end 20B comprises a pin threading. At least onegroove 80 is formed on the mandrel's outer surface 26, as best seen inFIGS. 4 to 6. The groove 80 is dimensioned (width, depth) to slidinglyaccommodate a protruding portion of the pin 88 that extends thereinthreaded through a hole 56 in the drag body 40. The lower retaining ring50 retains the drag blocks 42 within the drag body 40. The tubing anchorcatcher 10 may comprise one or more sets of grooves 80 and pins 88. Forexample, the tubing anchor catcher 10 may have three sets of grooves 80and three sets of associated pins 88 that are generally evenly radiallyspaced about the mandrel 20.

As depicted in FIGS. 5 and 6, the groove 80 may comprise a C-shape withshoulders 82 and 86 defining a first arm 80A of the groove 80 andshoulders 84 and 92 defining a second arm 80B of the groove 80. The twoarms 80A, B of the groove 80 are connected by central portion 80C thatis defined by walls 86, 87, 89 and 90. Wall 90 separates the first andsecond arms 80A, B.

As seen in FIGS. 5 and 6, which is an enlarged view of groove 80, aportion 88 a of the pin 88 protudes into the groove 80 and is seatedagainst the shoulder 92 in the run-in (i.e. un-set) position with theslips 62 retracted within the sip cage 60. To move the pin 88 to the setposition at shoulder 82, the tubing string can be manipulated at surfaceso as to move axially, i.e. by pulling or pushing, and rotationally,i.e. by turning, so as to similarly manipulate the mandrel 20. Themanipulation at surface may articulate the tubing anchor catcher 10between the run-in position and a set position. Due to the drag blocks42 frictionally engaging the inner surface 13 of the well conduit 12,the drag body 40 and the slip cage 60 remain relatively fixed as themandrel 20 and the rest of the tubing string, are manipulated fromsurface. As manderel 20 is pulled, for example about one inch, indirection 17, the pin 88 slides relative to mandrel 20 in direction A soas to engage the shoulder 84. Thereafter, the mandrel 20 can be lowered,for example about 6 to 7 inches, and turned, for example, a quarter turnto the left (i.e. about 90 degrees). The turning is about thelongitudinal axis of the tubing string and, therefore, the tubing anchorcatcher 10. This manipulation causes the pin 88 to move from shoulder84, generally along walls 89, 87 and 86 to rest in shoulder 86 of thefirst arm 80A. When the pin 88 is in shoulder 86, the tubing anchorcatcher 10 is in a pre-set position. The tubing string, and the mandrel20 can be turned freely to the left. Pulling the tubing string and,therefore, the mandrel 20 upwards, at least about an inch, in direction17 will cause the pin 88 to move into shoulder 82. When the pin 88 is inshoulder 82, at least the conical surface 54 has moved under the slips62 and the tubing anchor catcher 10 is set with the slips 62 extendingoutwards from the slip cage 60 to engage the inner surface 13 of thewell conduit 12.

In this embodiment, when viewed in vertical elevation with the top ofmandrel 20 upwards, groove 80 is in the shape of a reverse “C”, althoughthis is not intended to be a literal graphical description of shapesthat will work, as other shapes will work other than exact C-shapes asmay mirror images of the groove 80.

To release the slips 62, the tubing string and, therefore, the mandrel20 can be manipulated at surface. For example, the mandrel 20 can bemoved relative to the rest of the tubing anchor catcher 10, so that thepin 88 moves out of shoulder 82. As shown in FIG. 6, the mandrel 20 canbe pushed down so that the pin 88 moves along line F. With a quarterturn to the left the pin will move along line H and then a straightpulling up of the tubing string and mandrel 20 will cause the mandrel 20to move so that the pin 88 ends up in shoulder 84. When the pin 88 hasmoved out of the first arm 80A of the groove 80, the conical surface 54moves out from under the slips 62 and the spring 76 will cause the slips62 to retract back into the slip cage 60.

When the tubing anchor catcher 10 is in the set position and in theevent of a break in the tubing string, etc, which may cause the tubingstring to fall down into the well (i.e., in direction 16), the tensionin the tubing string is lost. This causes the weight of the tubingstring to bear on the upper safety sub 14A, which will bear on thebiasing member 94. The biasing member 94 will compress, from the weightof the tubing string above, and act against the upper edge 70A of thecone 70. This action causes the upper teeth 64A to more directly engageand bite into the inner surface 13 of the well conduit 12. For example,the greater the amount of tubing string weight that compresses thespring 94, the harder, or more directly, the upper teeth 64A will engagethe inner surface 13 of the well conduit 12. When the downwardly gripperteeth 64A are more directly engaged into the inner surface 13 of thewell conduit 12, the upper teeth 64A can hold the weight of the tubingstring above the tubing anchor catcher 10, for example, until such timethat the tubing string can be recovered at surface.

If it is not possible to move pin 88 in the groove 80 so as to unsetslips 62, for example due to packing of sand or other materials into thegroove 80, the slips 62 may be unset by applying a sufficient upwardtension on the tubing string and the mandrel 20. In one embodiment, theupward tension is of a sufficient amplitude to shear the pins 88, whichform the primary connection between the drag body 40 and the mandrel 20.Then the mandrel 20 may move upward (i.e. in the direction of arrow 17),relative to the drag body 40, which causes the second conical surface 54of the drag body 40 to move out from under the slips 62. This allows theslips 62 to retract from contacting the inner surface of the wellconduit. When the slips 62 are retracted, the tubing anchor catcher 10may be pulled out of the well conduit 12. For example, the pin 65 mayengage the lower shoulder 68B of the slot 66 so that the slip cage 60,and the drag body 40 do not separate. Alternatively, or additionally,the lower edge of the catcher body 40 may engage the lower safety sub 14b as the tubing string is pulled upwards towards the surface (i.e. indirection 17).

FIGS. 9 to 12 depict an alternative embodiment of a tubing anchorcatcher 100 with an upper end 100A and a lower end 100 b. The tubinganchor catcher 100 may comprise many of the same features as tubinganchor catcher 10. For example, one difference between the two tubinganchor catchers 10, 100 is that the pin 88 of the tubing anchor catcher10 may be sheared as a secondary release mechanism, as described above.In contrast, the tubing anchor catcher 100 may comprise a pin 188 thatis not designed to shear as a secondary release mechanism. The tubinganchor catcher 100 may comprise one or more shear pins 72 that aremounted on the lower cone 41 to drag body 40. The shear pins 72 are madeof a material that will shear in response to a lower shearing force thanthe shear force required to shear the pin 188. The second conicalsurface 54 is formed on the upper end of cone 41 (see FIG. 12). Cone 41slidably mounts about the external surface of the mandrel 20 so thatconical surface 54 in combination with conical surface 70B on cone 70compress together along mandrel 20 to force slip 62 into the setposition, as described above. The shear pins 72 provide a secondaryrelease of slips 62 by the application of a sufficient pulling force tothe tubing string so as to shear the shear pins 72. When the shear pins72 are sheared, the conical surface 54 can move from under the slips 62and the slips 62 can retract away from the inner surface 13 of the wellconduit 12.

The tubing anchor catchers 10, 100 are thus designed to anchor thetubing string from movement longitudinally along the well (in bothdirections, up and down the well) and from rotating. The anchoring isachieved by simple setting and release procedures that requirerelatively little movement of the tubing string. In this instance,setting is achieved by a small pull and left hand rotation of themandrel 20 (via the tubing string) that is adequate for the pins 88, 188to travel the short distances within the groove 80. Further, both tubinganchor catchers 10, 100 can prevent a broken tubing string from fallinginto the well bore by the compression of the spring 94 causing thedownward gripping teeth 63A to grip the inner surface 13 of the wellconduit 12, as described above.

In one optional embodiment of the present invention, the slips 62 may beconfigured to center either or both of the tubing anchor catchers 10,100 within the well conduit 12 by radially extending from the slip cage60 (see FIGS. 13 and 14). This may provide one or more by-pass spaces 78between the tubing anchor catchers 10, 100 and the inner surface 13 ofthe well conduit 12, which may create high flow areas for fluids (e.g.gas) and solids (e.g. sand) to pass by the tubing anchor catchers 10,100. The by-pass spaces 78 may also allow coil tubing to extend moreeasily past the tubing anchor catcher 10, 100. In the FIG. 14, which isprovided by way of example only, depicts by-pass spaces 78 with 1.0 inch(25.4 mm) radial clearance that are created between the 4.5 inch (114.3mm) OD of the slip cage 60 and the 6.5 inch (165.1 mm) ID of the wellconduit 12.

This optional embodiment of the tubing anchor catchers 10, 100 maypermit capillary cable to be carried downhole via the large by-passspaces 78. In particular, the fact that the tubing anchor catchers 10,100 is set and unset by longitudinal motion and a limited, quarter turn,permits its use with the capillary cable since the tubing anchorcatchers 10, 100 may avoid wrapping of the cable around the tubinganchor catchers 10, 100. In contrast, prior art anchors that requiremultiple full (360 degree) rotations—between two to nine full rotationsfor setting and unsetting—cause an undesirable wrapping of the cablearound the anchor, which can damage the cable. Alternately, the cablesmust be pre-wrapped when inserted with these prior art anchors, so thatthey unwrap as the anchor is twisted during setting, which is tediousand undesirable.

Optionally, the drag blocks 42 may be hardened, in comparison to priorart drag blocks, for a longer operational life. The slips 62 mayoptionally be made of solid high strength metal for superior durabilityand grip on the well conduit wall 13, and Inconel™ type springs 76 areemployed for improved resistance to H₂S and CO₂. Further, the surface ofthe mandrel 20 may optionally be coated with Teflon® for improvedresistance to H₂S and CO₂, and to help maintain mandrel strength.

While the above disclosure describes certain examples of the presentinvention, various modifications to the described examples will also beapparent to those skilled in the art. The scope of the claims should notbe limited by the examples provided above; rather, the scope of theclaims should be given the broadest interpretation that is consistentwith the disclosure as a whole.

What is claimed is:
 1. A tubing anchor catcher tool that is positionablewithin a well conduit for preventing movement of a tubing string, thetool comprising: a. a mandrel that is connectible at a first end and asecond end within the tubing string, the mandrel comprising anexternally facing groove; b. a slip cage that is slidably mountableabout the mandrel, the slip cage comprising a slip that is adapted forengaging the inner surface of the well conduit; c. a first cone elementthat is slidably mountable about the mandrel, adjacent the slip cagetowards a first end of the tool, the first cone element comprising afirst conical surface; d. a drag body that is slidably mountable aboutthe mandrel, adjacent the slip cage towards a second end of the tool,the drag body comprising a drag member that is sized for frictionallyengaging an inner surface of the well conduit, a pin for engaging theexternally facing groove, and a second conical surface; and e. a biasingmember that is slidably mountable about the mandrel adjacent the firstcone element for engaging the first cone element when the biasing memberis compressed; wherein the tool is articulatable between a run-inposition and a set position, when in the run-in position the slip isretracted into the slip cage and when in the set position at least thesecond conical surface is moved underneath the slip for extending theslip outward from the slip cage.
 2. The tool of claim 1, wherein thefirst end of the tool is an upper end and the second end of the tool isa lower end.
 3. The tool of claim 1, wherein the externally facinggroove comprises a C-shape with a first arm and a second arm that areconnected by a central portion.
 4. The tool of claim 3, wherein in therun-in position, the pin is positioned within a shoulder of the secondarm of the externally facing groove.
 5. The tool of claim 3, wherein inthe set position, the pin is positioned within a first shoulder of thefirst arm of the externally facing groove and the drag body is closer tothe biasing member than when the tool is in the run-in position.
 6. Thetool of claim 5, wherein the tool is moveable to a pre-set position,wherein the pin is positioned within a second shoulder of the first armof the externally facing groove, the second shoulder of the first arm isopposite to the first shoulder of the first arm.
 7. The tool of claim 6,wherein the pin is moveable within the externally facing groove betweenthe shoulder of the second arm to the second shoulder of the first armby longitudinally moving the mandrel in a first direction relative tothe drag body, then in an opposite second direction with a quarter turnrelative to the drag body, the pin is movable from the second shoulderof the first arm to the first shoulder of the first arm by moving themandrel in the first direction.
 8. The tool of claim 1, wherein when thetool is in the set position, the first cone element is movable under theslip due to the biasing member being compressed.
 9. The tool of claim 1,wherein the pin is shearable for providing a secondary releasemechanism.
 10. The tool of claim 1, further comprising a second coneelement that is mountable about the mandrel between the drag body andthe slip cage, wherein the second cone element defines the secondconical surface.
 11. The tool of claim 10, wherein the second coneelement is connectible to the drag body by one or more shear pins,wherein the one or more shear pins are shearable at a lower shear forcethan the pin and the one or more shear pins provide a secondary releasemechanism.
 12. The tool of claim 1, wherein the slip comprises upwardgripping teeth and downward gripping teeth.
 13. The tool of claim 1,wherein the drag body further comprising a cap screw that extendsoutwardly from the drag body through a slot that is defined by the slipcage, wherein the cap screw and the slot prevent the drag body and slipcage from longitudinally separating.
 14. The tool of claim 1, whereinthe slip comprises at least two slips.
 15. The tool of claim 14, whereinwhen the tool is in the set position, the at least two slips areengageable with the well conduit for centralizing the tool.
 16. The toolof claim 14, wherein when the tool is in the set position, the at leasttwo slips define a by-pass space therebetween.
 17. The tool of claim 14,wherein the drag body further comprising at least two cap screws thatextend outwardly from the drag body each through an associated slot thatis defined by the slip cage, wherein the at least two cap screws and theassociated slots prevent the drag body and slip cage from longitudinallyseparating, and wherein the at least two cap screws and the associatedslots are positioned between the at least two slips.
 18. The tool ofclaim 1, wherein the mandrel comprises at least two externally facinggrooves that are associated with at least two pins of the drag body. 19.The tool of claim 1, wherein the at least two externally facing groovesand the at least two pins are generally evenly radially spaced about thetool.